Well completion



A. F. RHODES ETAL June 1, 1965 Filed Feb. 24, 1959 WELL COMPLETION 11Sheets-Sheet 1 /l//en Rhodes (/0/7/? 6. Jackson, (/l.

l V////am 77/,0/9 ff MENTOR:

ATTORNEY June 1, 1965 A. F. RHODES ETAL 3,1

WELL COMPLETION Filed Feb. 24, 1959 11 Sheets-Sheet 2 ATTORNEY June 1,1965 A. F. RHODES ETAL 3,186,486

WELL COMPLETIQN Filed Feb. 24, 1959 11 Sheets-Sheet 3 INVENTQRS BYQ/LZZig y ATTOR/VEV June 1, 1965 A. F. RHODES 'ETAL WELL COMPLETION 11Sheets-Sheet 4 Filed Feb. 24. 1959 /|//e/7 F. Rhea es (Job/7 6.doc/(Jon, L/l.

W////a /77 C. Trvp/eff INVENTORS ATTORNEY June 1, 1965 Filed Feb. 24,1959 A. F. RHODES ETAL 3,186,486

WELL COMPLETION 11 Sheets-Sheet 5 ATTORNEY June 1, 1965 A.F.RHODES ETALWELL COMPLETION Filed Feb. 24, 1959 11 Sheeiis-Sheet 7 ATTORNEY June 1,1965 A. F. RHODES ETAL 3,186,486

WELL COMPLETION Filed Feb. 24, 1959 11 SheetsSheet 8 wm a.

ATTOR/Vfy June 1, 1965 A. F. RHODES ETAL WELL COMPLETION 11 Sheets-Sheet9 Filed Feb. 24, 1.959

BY Mg 5%;

June 1, 1965 A. F. RHODES ETAL WELL COMPLETION 11 Sheets-Sheet 10 FiledFeb. 24, 1959 A//en F. Rhodes ATTOR/Vf) United States Patent Tex.)

Filed Feb. 24, 1959, Ser. No. 795,105 6 Claims. (Cl. 166-665) Thisinvention pertains to methods and apparatus for underwater wells. Theinvention contemplates such fea tures in connection with underwaterwells as drilling, completion, production, maintenance, and workoveroperations.

A principal object of the invention is to provide satisfactory methodsand apparatus for creation and completion of oil wells beneath a body ofwater.

Another object of the invention is to provide an underwater wellcompletion which can be reworked and from which the separate componentscan be removed, overhauled, and/ or replaced.

The completion would further provide control of the well during allsteps of the method and during all steps of assembly of the apparatus,and such are also objects of the invention.

Another object of the invention is to provide methods and apparatuswherein the completion may be opened for access therethrough byconventional wire line methods or other suitable manner.

Another object is to provide such methods and app-aratus including aboat, barge, or other float, whereby the operations may be controlledand/or performed at the water surface.

A further object of the invention is to provide methods and apparatusfor creating, and completing wells which are satisfactory for thecomplete operations of creating and completing wells, for operationsafter completion of the wells, and which are convenient, of reasonablecost, and relatively simple.

Briefly, the invention contemplates methods and appa ratus forcompletion of underwater wells. A boat or other floating vessel carriessubstantially all apparatus necessary for performing the method and forassembling the apparatus. The boat has an opening through its decks andhull through which the underwater operations are performed. Guide linesare included for lowering of certain components of the apparatus to thebottom of the body of water. The well completion is removably assembledsuch that the entire completion or a part thereof may be removed, thelatter enabling reworking of the well after completion and therecompletion of additional producing Zones, and the removabilitycharacteristics of the completion components facilitating control of thewell during both drilling and completion thereof.

Other objects and advantages of the invention will appear from thefollowing description of preferred embodiments, reference being made tothe accompanying drawings, of which:

FIGURE 1 is a side elevation, partly in vertical section, of a preferredform of apparatus according to the invention at one stage of assemblythereof, and illustrating the method of the invention during that stageof assembly, the portion beneath the break lines being enlarged;

FIGURE 2 is an enlarged partial elevation, partly in vertical section,showing the apparatus and method at a different stage of assembly;

FIGURE 2A is a partial vertical section showing the lower part of FIGURE2 at a different stage of assembly;

FIGURE 3 is a perspective view of a connection element of the apparatus,a portion thereof being cut away to show features of the interior of theconnection element;

FIGURES 4A and 4B are enlarged partial elevations,

partly in vertical section, FIGURE 4A showing the upper portion, andFIGURE 4B the lower portion, of a part of the apparatus and method in adifferent stage of assembly;

FIGURE 40 is a partial elevation, partly in vertical section, showingequipment at the floating vessel in conjunction with the showing ofFIGURES 4A, 4B;

FIGURES 5A and 5B are like FIGURES 4A, 4B, showing the apparatus andmethod at still another stage;

FIGURE 6 is an elevation, including a portion thereof shown as aschematic represenation, of a secondary assembly of the apparatus;

FIGURES 7A and 7B are, respectively, partial vertical sections showingthe upper and lower portions of the apparatus and method at stillanother stage of assembly, for one size of surface casing;

FIGURES 7C and 7D are similar to FIGURES 7A, 7B, showing an alternativeform in which a smaller surface casing is used;

FIGURES 8A and 8B are partial elevations, partly in vertical section,showing the upper and lower parts, respectively, of another condition ofthe apparatus and method;

FIGURE 9 is a partial elevation, partly in vertical section, ofapparatus and method at another stage;

FIGURE 10 is an elevation, partly in vertical section, showing theapparatus in its final form, the underwater well being completed;

FIGURE 11 is a partial elevation, partly in vertical section, of amodified form of apparatus; and

FIGURE 12 is another partial elevation, partly in vertical section,showing another modified form of the part of the apparatus shown inFIGURE 11.

Referring now in detail to the drawings, the apparatus and method willbe described simultaneously. A floating vessel 20 carries, usually onits main deck 21, a derrick or drilling mast 22 as support means for usein drilling, completion, or workover of a well. The floating vessel 20may be of any type suitable for transporting over a water surface thepersonnel and the equipment herein described, and for supporting sameduring use in the manner described according to the method. Floatingvessel 20 carries auxiliary apparatus including the mooring winches 23,a plurality of which are provided, reels 24 for hoses, to be described,cabins 26 for technical personnel and crew, a helicopter landingplatform 27 atop the cabins, and stored materials (not shown) used indrilling and completing the well, and in maintaining the personnel, suchas drilling mud and components thereof, cement, fresh water, provisions, and the like, and miscellaneous equipment such as mud pumps,tanks, test equipment, hoisting equipment, cranes, logging units,anchors, cement pumps, oflices and equipment therefor, galley andequipment therefor, and the like. In other words, vessel 20 is fittedout with the usual equipment for comfort and safety of the personnel andoperations of the vessel, and the equipment necessary to carrying outthe method to be described, and many other items not specificallymentioned are or may be included.

When a well is to be drilled at an underwater location, the floatingvessel 20 (FIGURE 1) is floated upon the water surface to above thepoint at the waters bottom 30 at which the well is to be drilled, or thewell site. After the vessel has been moored securely, a concrete guidering 32, or base, is lowered to the underwater bottom on two parallelmanila lines 33, 34, secured to vessel 20 at their upper ends. This ringserves as a base element through which the drill string is lowered, andas anchoring means for lines 33, 34.

Still referring to FIGURE 1, and also to FIGURE 2, ring 32 maintains itsposition on bottom 30 because of its weight, and has lower ring shapedflanged portion 36 which sinks into the mud at the bottom. Ring 32 isfabricated of steel rod reinforced concrete, the rods being designatedby reference numeral 37, and continuations 38 of the rods above the ringare welded to the guide means (manila lines33, 34) connections to anchorthem to the ring. The drill string 42 (FIGURE 1) is guided through thecenter opening of ring 32 by a composite bit guide 43 engaging the drillstring 42 and slidingly engaging the manila 'lines 33, 34. Guide 43 hasa central ring 44- welded to two connector plates 45 in turn each weldedto a laterally extending arm 46 having a tubular collar 47 carried atits extending end to slidingly receive one of the lines 33, 34. The arms46 are coaxially aligned. Ring 44 is of a size large enough to fitloosely around the drill string assembly but small enough to preventmovement of the bit (to be described) therethrough. Ring 44 will rideupon the bit as the bit is moved from vessel 2t to ring 32 or from ring32 to vessel 20. When the bit is beneath ring 32, guide 43 rests abovering 32 and the drill string is slidingly moved through ring 44. Asstring 42 is moved up or down, the collars 4'7 slide along lines 33, 34,and thereby the string 42 is guided j centrally between the lines andthrough ring 32. This guiding action is effective at any intermediatepoint along the lines between vessel Ztland ring 32.

The initial segment 50 of the hole is drilled by a bit 51 carried at thelower end of drill string 42. Fluid circulation for the removal ofcuttings from the hole is accomplished by pumping sea water through thedrill string and out through the bit and allowing the circulating waterand cuttings suspended therein, to exhaust, from the hole into the bodyof water 54.

The initial segment of the hole is usually about 300 to 500 feet invertical depth. To isolate the action of the waves which are transmittedto the drill string through the floating vessel 21), a slidinglongitudinal connection 55 is installed intermediate the length of thedrill string at a point above the bit. This permits the maintenance of aconstant Weight on the bit during-drilling.

After the initial segment 56 of hole has been drilled, drill string 42,including the bit 51, is removed from the hole, and hoisted back alonglines 33, 34 to aboard the floating vessel. A casing 56 (FIGURE 2)having an open guide shoe 57 carried at its lower end is lowered intothe initial well hole 51), using a retrievable guide (not shown),similar to guide 43, which positions the lower end of the casing overthe hole with relation to the manila guide lines 33, 34. A guide funnel6t and casing After the described assembly dl is in place on ring 32, itis cemented in place. For this operation, a drill pipe 70 ofconventional form but of smaller diameter than drill pipe 42, is runthrough assembly 61, the smaller drill pipe 79 carrying around its lowerend one or more annular rubber seal cups 71 of conventional form to sealthe annular space between the smaller drill pipe 70 and the interior ofcasing 56 (FIGURE 2A). A centralizer 72 is carried at the lower end ofstring 7d. String 70 is guided through assembly 61 by guide means 43,heretofore mentioned, and a sliding connection (not shown) similar tosliding connection 55 is provided in the string. Cement is pumpedthrough string 71) from vessel 29, the cement passing out of the lowerend of casing 56 and guide shoe 57 to fill the hole space around casing56 and assembly 61 up to ring 32 and plate 62. Cement is pre vented fromrising in casing 56 by sealing cups 7 1. After the resulting cementformation 75 (FIGURES 2A and 2) has hardened, the entire assembly in thehole is secured in place, and the next section of the hole below holesection 5t) may be drilled therethrough.

Manila lines 33, 34 are cast off from vessel. 29, or retrieved, afterthe guide cables 67, 68 are in place. Cables 67, 68 are used thereafterin the same manner as were the temporary manila lines.

After the conductor casing assembly 61 has been cemented in place andthe cement mixture 75 has been given suificient time to harden, ablowout control assembly 76 (FIGURES 4A, 48, 5A, 5B) is lowered intoplace with drill string 7%) and connected to the upper end of theconductor casing assembly with remote connection 65, previouslymentioned- The lower part 64 of this safety joint 65 has been describedpreviously as forming supporting assembly 61 are carried at the upperend of the casing. The lower part of the guide funnel 60 is in the formof a horizontal ring flange 62 secured about the a tubular lower part ofthe funnel and which rests on the upper surface of ring 32 and coversthe center opening through the ring. Casing 56 is lowered into the wellhole with the rig hoisting machinery aboard vessel 20 until the funnel613 and casing supporting assembly 61 are attached to its upper end.

The casing assembly comprises, beginning at its lower end, the guideshoe 57, conductor casing 56, the casing supporting assembly 61including the lower end 64 of a remote connection means, such as thesafety joint 65 shown in FIGURE 3, installed inside the upper end of thecasing supporting assembly, the flange landing base 62, guide funnel 6iand two or more guide cables 67, 63 connected to the guide funnel atperforate eyes 6? thereof. vessel to rest on concrete guide ring 32 bymeans of the guide cables 67, 68 or the drill pipe 42 attached to theassembly by said remote connection means 65 and supported at its upperend by the rig hoisting machinery aboard vessel 20. If drill pipe 42isused to lower the assembly, the guide cables 67, 63 are nonethelessprovided, but are allowed to slackly follow the assemblyas it islowered. If used, drill pipe 42 is disconnected at safety joint 65 andhoisted back aboard vesselZtl after assembly 61 is in place.

This combined assembly is lowered from the an upper part of theconductor casing assembly 61. The safety joint is shown separately inFIGURE 3. The upper part 77 of the safety joint forms a lower part ofthe blowout control assembly 76. The assembly is supported and loweredby a drill pipe which is connected to a conventional landing tool (notshown). The landing tool is grooved to provide a seat for the pipe ramsin a lower ram-type blowout preventer of assembly 76. The pipe rams inthe p'reventer are closed against the landing tool thereby providing aconnection between assembly 76 and the drill pipe support. With suchconnection having been made, the assembly 76 is then lowered intoposition with the drill pipe which is in turn supported and controlledby the rig hoisting machinery aboard vessel 20.

Referring now to FIGURE 3, which shows the safety joint 55, upper part77 of the safety joint includes an outer tubular barrel 81) which isscrewed onto an upper connector 81, the upper connector having an upperthreaded socket formation 82 for screwing onto other apparatus (e.g.,assembly 76). A sealing barrel 83 is also screwed to connector 81 but atthe inside thereof and spaced inwardly of outer barrel 80. A latchingsleeve 85 is slidably disposed between outer barrel 30 and sealingbarrel 83, and a helical spring 86 is disposed under compression betweenthe lower end of connector 81 and the upper end of latching sleeve 85.Latching sleeve 85 has a plurality of downwardly projecting latchinglugs 37 at its lower end for latching the barrel in place. A pluralityof helical keys 88 formed on the interior surface of outer barrel 8%)are each disposed with their upper end against'a side of one of thelatching lugs.

The lower part '64 of safety joint 65 includes a mandrel 90 having lowerconnection threads and an upwardly facing annular shoulder 91 abovewhich the outer diam eter of the mandrel is decreased. The decreasedpart 92 of mandrel 90 is slidingly receivable within the axial opening93 of the latching sleeve 85, and the larger part of mandrel 91) isslidingly receivable within barrel 80. The larger part of mandrel 9%)has helical grooves 95 formed therein which are spaced therearound toregister with the helical keys 88 of outer barrel 80. A plurality ofcooperable slots 96 are formed in shoulder 91 to receive the lugs 87 atthe lower end of the latching sleeve 85.

Spring 86 permits latching sleeve 85 to be moved relatively upwardlyupon contacting shoulder 91 as the two parts 64, 77 of the connectionare telescopically moved together. Helical keys 88 first enter helicalgrooves 95 and cause upper connection part 77 to be rotatedcounterclockwise about its axis relative to lower connection part 64 asconnection parts 64, 77 come together. Lugs 87 rotate slidingly alongshoulder 91 as keys 88 move helically further into grooves 95, and afterkeys 88 are entirely within grooves 95, lugs 87 register with slots 96and are snapped thereinto by downward compressive force of spring 86 onlatching sleeve 85. Keys 88 are then locked within grooves 95, and theconnection parts 64, 77 are maintained connected to resist and transmittension, compression, and torsion forces thereacross. Although thesafety joint is shown having upper and lower thread connectionformations other types of connections may alternatively be provided.

Safety joint 65 may be released, in the conventional manner, byinserting a releasing spear carried at the end of a wire line (notshown) into the safety joint opening 93. The spear has spring actuatedoutwardly extending members which engage releasing spear groove 98 oflatching sleeve 85, and when the spear is pulled upwardly by the wireline it moves latching sleeve 85 upwardly to compress spring 86 andremove the lugs 87 from slots 96 and thereby enable keys 88 to be movedout of grooves 95.

Blowout control assembly 76 has two pairs of oppositely disposedlaterally extending arms 100, 101 which engage guide cables 67, 68 atperforate end collars 102, 103, respectively, to guide the blowoutcontrol assembly into position as it is lowered so that safety jointpart 77 will engage over safety joint part 64 of assembly 61.

The blowout control assembly 76 (FIGURES 4A, 4B, A, 5B) comprises safetyjoint part 77 on the bottom connected to a double control gate,hydraulic operated ram type blowout preventer 105 on top of which isconnected a mud control spool 106 having a remote operated valve 107installed on a side outlet of the spool. Above the spool is connected abag type hydraulic operator blowout preventer 108 on top of which isconnected a mud return spool 109 with a mud return hose 110 connected toa side outlet of the spool. Mounted on top of the spool 109 is anotherbag type hydraulic operated blowout preventer 112, but of a lowerworking pressure rating than preventer 108.

Referring now to FIGURE 6, blowout control assembly 76 is powered andoperated from a remote location by means of hydraulic pressure. Theblowout control assembly 76, previously described consists of fivehydraulically operated units as follows: the first unit comprises blindrams with shear blades at the lower end of the double control gateram-type blowout preventer 105; the second unit comprises pipe rams inthe upper portion of double control gate ram-type blowout preventer 105;the third unit comprises bag type blowout preventer 108 locatedimmediately above the mud control spool 106; the fourth unit compriseslow pressure bag type blowout preventer 112 located immediately abovethe mud return spool 109, and used for sealing purposes only; the fifthunit comprises remote hydraulically operated gate valve 107 connected toa side outlet in the mud control spool 106.

In addition to these items, there are attached to the submerged blowoutcontrol assembly 76, two gas charged hydraulic accumulators 115, onlyone being shown in FIGURE 6, and a piston actuated threeway remotecontrol valve 116 located underwater adjacent blowout preventer 105.Operation of all of the hydraulically operated units except the blindrams (of blowout preventer 105) is controlled by the action of hydraulicfluid channeled from the hydraulic pressure accumulator unit 117 whichis aboard vessel 20 and directly connected by fluid lines to theunderwater operating units through the bank of control valves 118. Thecontrol valves 118 are four-way pipe valves arranged as shown in thedrawings to channel hydraulic fluid into the opening chambers of theblowout preventer units when in one position and into the closingchambers of these same units when in the other position. Operation ofthe gate valve 107 connected to the side outlet of the mud control spool106 is controlled by hydraulic pressure for opening and is closed by aspring when hydraulic pressure is released. This unit is controlled by asingle valve 119 shown in FIGURE 6.

Operation of the blind rams in the lower portion of the ram type blowoutpreventer is powered through two hydraulic accumulators mounted on theblowout control assembly and controlled by the piston actuated three-wayremote control valve 116. Operation of this portion of the system issuch that, with the check valve 120 in the supply line 121 from thehydraulic source 117 on the vessel to the hydraulic accumulators 115attached to the blowout control assembly 76, as shown in FIG- URE 6, allhydraulic control lines between the vessel and blowout control assemblycan be broken after the three-way remote control valve 116 has beenoperated to close the blind rams, and these rams will remain closedunder hydraulic pressure held within accumulators 115 for a considerableperiod of time (until leaks result in substantial dissipation of thepressure). This feature permits immediate closure of the well hole inany type of emergency. It is particularly valuable in case where one ofthe vessels mooring lines is severed and the vessel begins to drift offlocation. In such a situation the blind rams of the ram type blowoutpreventer 105 can be closed, and the action of the shear blades on theserams will sever a pipe in the hole running through preventer 105 and therams will seal the hole. The hole is then protected and formationpressures controlled by the closed blind rams under the hydraulicpressure within the accumulators attached to the blowout controlassembly.

The hydraulic control lines which extend from vessel 20 to blowoutcontrol assembly 76 are indicated by reference numerals 76a, 76b, 76c,76d, 121, 76e, 76), the function of each of which will be apparent fromthe showing of FIGURE 6. The break indications in these lines indicatethe locations of the elements of FIGURE 6, those to the left hand sideof the breaks being parts of assembly 76 and submerged therewith, thoseto the right hand side of the breaks being aboard vessel 20, theconnecting lines communicating therebetween through the Water. The breakindications in the drawing also indicate the lines which are exposed tobeing broken, as mentioned above.

The hydraulic liquid tank 118a contains a supply of hydraulic liquid,and receives return thereof from control valves 118 through returnmanifold pipe 118b. Hydraulic liquid is pumped from tank 118a by dualpressuring pumps 117a, 117b, each of which provides a safety pumpingfacility in case of failure of the other. The hydraulic liquid pumped bypumps 117a, 117b is delivered to hydraulic pressure accumulator unit 117and/or into line 121.

Blowout preventer 112 is used to provide sealed connection with a mudreturn hose 123 (FIGURE 4A) or with a rotating seal 124 (FIGURE 5A) asdesired. These sealed connections are of a form conventional in the art.A guide means 130, having perforate ends 131, 132 receiving guide cables67, 68, and having a central opening 133 to receive mud return hose 123or rotating seal 124, is provided for guiding the hose or seal into theupper end of preventer 112, which is then closed therearound to form asealed connection.

An upwardly facing conical guide funnel 135 is welded around the upperaxial opening of preventer 112 to assist entry of pipes or equipmentthereinto. A flange 136 about the upper end of the conical part of thefunnel provides reinforcement. against shock of landed equipment. Thetwo opposite guide anns1tltl, previously mentioned, are weldedtoopposite sides of funnel 135 as well as to the upper surface ofpreventer 112. V V The next step, preparatory to drilling the next holesection 1.13 below upper hole section 50, is to install the mud returnhose 123 (see FIGURES 4A, 4B). The hose is reeled oif of a hose reel 24aboard vessel 20 and lowered through the well 141 beneath derrick 22tobottom. The guide means 130 near the lower end of the hose slides downcables 67, 68 to assure entry of the lower end of the hose into funnel135 and .preventer 112. Preventer 112 is then closed about the hose toprovide a closed passage through the hose and preventer assembly '76. Atthe upper end of hose 123, atvessel 213 (see also FIGURE 4C), there isprovided a sliding connection 141, to absorb motion of vessel 20 on thewater, and thereabove a bell return nipple 142 having side outlet 143for discharge of fluids passing up through hose 123 to a'tank 144 aboardvessel 29. l

With mud return hose 123 in place, suspended from vessel 26 within well14-5 and beneath derrick 22, the next segment or section 138 of the holeis drilled (FIGURES 4A, 4B) by running drill string 71 with drillcollars 145 and drill bit 146 carried at its lower end, through hose123, blowout preventer assembly 76, assembly 61, and casing 56, string70 being supported and operated by the equipment aboard vessel 21). Thedrilling commences by drilling through cement 75 within casing 56 andshoe 57, after which drilling may be continued to the desired depth ofhole segment 138. A second sliding connection 148 is provided in thedrill string above assembly 76 to further isolate the drill bit fromvessel motion, this second sliding connection beinganalogous to slidingconnection 55 of FIGURE 1. The sliding connectionspermit a constantweight on bit 146 to be maintained during drilling regardless of motionof vessel 20.

Drill pipe 71 at its upper end at vessel 20, is connected to means 149on the floating vessel for rotating the 'drill string to drill the well,to support weight of the assembly, and to provide for the circulation ofdrilling fluid under pressure in the conventional manner. Circulation ofthe drilling fluid is accomplished in a conventional manner'from mudpumps carried aboard the vessel to the drill bit at the bottom of thehole. Drilling .fluid, and cuttings suspended therein, are circulatedfrom the drill bit up through the annular space between the drill pipeand hole, through the conductor casing assembly and blowout controlassembly, and through the mud return hose, and are returned to mud tanks(not shown) aboard the vessel through side outlet 143 of bell returnnipple 142 and through tank 144 (see FIGURE 40).

.Drilling can proceed in this manner until such hole depth is reached atwhich it becomes desirable to set an additional string 155 (FIGURE 8B)of easing. At this stage of operations, or prior to this time, if it isdesirable to remove the blowout control assembly 76 (FIGURES 4A, 48) tochange rams, perform maintenance, make repairs, inspect, and the like,this can be done and effective control of well pressures can at the sametime be maintained. This is done by the use of a latching plug 156(FIGURE 2) which is set in casing hanger seat 157 within the casingsupporting assembly 61. The latching plug seals off the well boreagainst formation pressures and permits the safe removal of blowoutcontrol assembly76. Latches 158 of hole plug 120 engage with a groove orslot 159 in thecasing hanger seat. When the blowout control assembly 76is replaced in position and properly connected to the conductor casingassembly, in the manner already described, the plug can then be removedwith a plug releasing device (not shown) inserted through the blowoutcontrol assembly. The lower end of the plug releasing device engages theupper grooved mandrel 160 of the hole plug and when hoisted releases thelatches and removes the plug. 1

, 8 I After segment 138 of the hole has been drilled, casing is run infrom vessel 21 through mud return hose 123, blowout control assembly 76,casing supporting assembly 61, and casing 56. A latching type casinghanger (FIGURES 7A, 7B, 8B) is installed on the upper end of the casingstring 155 and this hanger supports the easing string in tension fromits support at casing hanger seat 157 provided in the casing supportingassembly 61. A safety joint mandrel 9%, identical except for size withthe mandrel 911 of safety joint 65 of FIGURE 3, is attached to the upperend of easing hanger 165, providing a means for connecting other devicesto the upper portion of casing string 155. The casing string with hanger165 attached thereto is lowered into position by a landing assembly (notshown) which is connected to the casing string with the safety joint.Above the safety joint on the landing assembly, there is a suificientlength of easing (not shown) identical in size to the casing string 155being run to provide the same diameter pipe through the ram type blowoutpreventer 1115. Above this upper length of casing, drill pipe 70 isconnected to the landing assembly by means of the sliding connection148, previously described. With the casing string resting in the hangerseat, drilling fluid is circulated down through casing 155 from vessel20 and up the annulus around casing 155 and is returned to the vesselthrough a plurality of circularly spaced side outlet connections 1.66below the casing hanger seat 157 in the. casing supporting assembly 61.From these side outlet connections, the fluid is conducted to a pointabove the flanged landing base 62 by tubings 167, which are connected tothe mud circulation system aboard vessel 20.

With circulation thus established, the hole can be conditioned forcementing by the circulation of drilling fluid as described for adesirable length of time. The casing can then be cemented back to apoint inside the conductor casing, using the same circulation path asthat previously described for the drilling fluid- This cement isdesignated by reference numeral 171 and is below cement 75. Cementinside the casing is displaced with drilling fluid to a desirable pointabove the lower end of casing string 155. With the cement in place andset the landing assembly can then be removed by disconnecting the safetyjoint. With cement both inside and outside the casing, it is nowpossible to remove the blowout control assembly 76 (FIGURES 4A, 4B) andthe mud return hose 123 from the well. If it is desirable to drill to agreater depth and to set additional strings of easing, another casingsupporting assembly, with the lower part of a safety joint carried atthe upper end thereof, and with a guide funnel surrounding the safetyjoint part, can be secured to the upper end of casing 155 and its hanger165. The casing setting operation which has been described in connectionwith casing 155 can be repeated for successively smaller concentriccasings as desired. Two or more casings can be supported at seats withinassembly 61 in the manner of casing 155, or the casings may be supportedsuccessively, each from the preceding casing in the well.

Referring now to FIGURES 7A, 7B, particularly, and also to the otherdrawings, casing supporting assembly 61 will be more fully described.Assembly 61 includes an elongate tubular lower casing head body 181)having lower threaded socket 181 screwed onto the upper end threads ofconductor casing 56. Body 1811 is thickened inwardly at its lower endand the previously mentioned conical seat 157 is formed therewithin. Anupwardly enlarging adapter mandrel 182 is screwed onto the outwardlythreaded upper end of body 1511. Mandrel 182 has an upper threadedsocket 134 into which is screwed the lower threaded end .of lower safetyjoint mandrel 9d of the safety joint 65, previously described (FIGURE3).

Casing hanger 155 is seated on seat 157, safety joint mandrel 913a beingscrewed into a threaded socket at the upper end of the hanger, andcasing 155 being supported from the hanger at threads 135 thereof.Hanger 165 has a seat ring 186 movably disposed in a recess around itslower end, and a sealing ring 187 of resilient material, such as rubber,is disposed between the upper end of ring 186 and the upper end of therecess. Weight of casing 155 causes axial compression of ring 187 toform a fluidtight annular seal around the hanger. A plurality ofreleasable outwardly biased latches 188 around the hanger above thesealing ring enter the groove 159 to hold the hanger down on seat 157.

Mandrel 90a forms the lower part of a safety joint 65a, which issubstantially identical, except for size, with safety joint 65, FIGURE3. Safety joint 65w has upper part 77a, like part '77 of safety joint 65except that it has exterior threads instead of an interiorly threadedsocket, onto which is screwed an upper casing head body 199 which hasspaced interior upwardly-facing conically tapered seats 191, 192 forsupporting two additional strings of concentrically disposed casing(shown in FIG- URE 7D in a modified arrangement). A safety joint mandrel90b is connected at the upper end of casing head body 190 and is locatedinside an upper guide funnel 193 which is also connected to the upperend of the casing head body, for example by welding it thereto. Theguide funnel 60 is welded to the upper end of adapter mandrel 182.

The described assembly is lowered into place by a handling string (notshown) consisting of a drill string including a sliding connection andhaving the upper part of a safety joint at its lower end connected tomandrel 90b.

With the described assembly in place, the blowout preventer assembly 76shown in FIGURES 4 and 6, or a blowout preventer assembly identicaltherewith except adapted for higher working pressures, can be connectedin the previously described manner to safety joint mandrel 9%, an uppersafety joint part 77b being connected at the lower end of the blowoutpreventer assembly. The mud return hose 123 is now lowered into positionand connected as previously described. With the apparatus thusassembled, it is now possible to drill additional hole as desired. Witha drilling assembly similar to that previously described, other casingssuch as strings 195, 196, shown in FIGURE 7D, may be run into the holeand supported by hangers resting on seats 191, 192 of casing head body190. The apparatus as described will permit the use of four separatestrings of casing together with a string of production tubing 197 insidethe smallest production casing. Additional strings of easing may beincorporated into the apparatus by the use of large diameter conductorcasing. After drilling of the. well has been completed and productioncasing set and cemented, the well can then be completed and producedwith apparatus which will rest below the surface of the water Referringto FIGURES 7C, 7D, casing hangers 165a, 165b, both of which are ofdesign similar to hanger 165, are provided to support the casings 195,196, respectively, on seats 191, 192 of body 190. These hangers may havethe double hold-down latches 199 as shown, or may have single latches asshown for hanger 165. It is to be understood that this assembly may beprovided identically at body 190 in the embodiment of FIGURES 7A, 7B.

Casing hanger 1651; for supporting the production string of casing 196has screwed to its upper end a hanger seat 219 for supporting theproduction tubing 197. With the production hanger 16511 and tubing seat210 latched into position as shown within the casing head body, theproduction tubing can then be lowered into position inside productioncasing 196. The tubing is run-with a tubing hanger 211 which has alatching and sealing seat 212 formed at its upper end. The tubing stringis lowered into position with a landing string (not shown) attached tothe upper portion of the tubing seat 210 with internal left hand pipethreads 213. After the tubing hanger has been landed in its seat, thelanding string can be disconnected at the left hand thread connection bysuitable rotation of the string, and removed.

A standardtype of blank sealing plug (not shown) may now be lowered intothe latching and sealing seat 212 within the production tubing hanger211. Such plugs are latched in place with a setting tool (not shown)supported by a pipe string from the vessel. The pipe string is thenremoved. This leaves the well bore closed or blanked off, and undercontrol, and permits removal of the mud return hose and blowout controlassembly and subsequent installation of a Christmas tree assembly.

Referring now to FIGURES 7C and 8A, 8B, the Christmas tree assembly 215has a safety joint barrel 77b at its bottom connected to safety jointmandrel 90b, there being a side outlet 217 in the upper portion ofbarrel 77b, which provides a connection to the annular spacetherewithin. Attached to this side outlet is a remote operated valve 218which in turn is connected by a flexible tube 2197leading to aproduction storage platform or other control station, not shown.Attached above the safety joint barrel 77b, see FIGURE 8A, is a remoteoperated master valve 221, above which is a fitting 223 having a curvedside-branching pipe connection 224 to which is connected a remoteoperated wing valve 225. Connected to this remote operated wing valve isa production flow line 228 which also leads to a production storageplatform, not shown. Lines 219, 228 are constructed of flexiblematerial, such as rubber, for a distance from the underwater well sitesufiicient to permit raising and lowering the Christmas tree to and fromthe surface of the water, without placing undue strain on the lines. Atother parts, the lines may be constructed of conventional oilfieldtubular goods if desired. EX- tending above fitting 223 is a length oftubing 229 sufficieut in length and diameter to be used as a passage forinsertion of conventional wire line logging and workover tools. Attachedto the upper end of tubing 229 there is a guide funnel 230 inside ofwhich there is a small diameter safety joint mandrel 900 of a safetyjoint 650. Guide arms 235, 236 are provided on the Christmas tree, thelower arms 235 at the lower end around the safety joint barrel 77b andthe upper arms 236 at the upper end attached to the upper guide funnel230. The above described assembly is lowered into position with a pipestring (not shown) connected as has been described to the safetyjointmandrel 90c in the upper guide funnel. The assembly is guided intoposition by the guide arms having end eyes about the guide cables. Whenlowered over the safety joint mandrel 90b of safety joint 65b at theupper end of the casing head body 190, the safety joint barrel 77battached to the lower end of the Christmas tree assembly automaticallyconnects to the safety joint mandrel. Casing 196 and tubing 197 aresealed ofl. from each other by a sealing barrel 237 within the safetyjoint barrel as best shown in FIGURE 7C. 'Barrel 237 is supported by aplurality of the bracket arms 237a welded in radial positions spacedaround barrel 237, their outer ends being welded to the interior surfaceof the mandrel b of safety joint part 77b. If a superior seal isdesired, a sealing barrel 238 may also be installed within the Christmastree and tubing hanger as shown in FIGURE 7C. Sealing barrel 237 hasinterior packing elements 240, 241 disposed in circular recesses whichseal about the lower end of a tube 242 threadedly connected to the lowerend of the Christmas tree at 243, and about the upper end of the tubinghanger, respectively. Sealing barrel 238 has packing ring 244 andlatches 245 which seat and engage at sealing and latching seat 212 ofthe tubing head. A tubular sleeve 246 may be urged downwardly in atubular upper end recess 247 of barrel 238 to urge and hold the latches,which have inner tapers, outwardly to latched position. A groove 248around the top of sleeve 246 allows it to be picked up to releasethelatches. A seal ring 249 seals between barrel 238 and tube 242.Barrel 238, of course, cannot be put into v sel '20.

' l it place until after the blank plug, described as seated at latchingand sealing seat 212, has been removed.

The Christmas tree being in place as described, the blank plug in thelatching seat within the tubing hanger can then be retrieved by means ofa wire line operated retrieving tool so that barrel 238 can be set inplace. It is now possible to install additional control apparatus suchas blowout preventer 252 above the Christmas tree by attachment to thesafety jointmandrel 990 within guide funnel 23th as shown in FIGURE 8A,preventer 252 including guide arms 253, 254 and funnel 255 of the typeheretofore described. With such control apparatus in position, togetherwith the control afforded by the remote operated valves 221, 225 of theChristmas tree, the well can be perforated, swabbed, logged, andfractured, and worked upon in any other known manner possible withconventional wire line tools, all of 7 this being accomplished from avessel at the water surface.

After the well has been completed and flow tested, if desired, theChristmas tree can then be closed up at the top and the drilling vesselremoved from the well site. This is done as follows: All tools areremoved from the well, and the blowout preventer 252 is removed bydisconnection at safety joint 65c, and raised to vessel 20. (These stepsare carried out after the Christmas tree master valve 221 has beenclosed.) The top of the Christmas tree is closed by a blank safety jointbarrel 258 having a threaded-through wire line release cable 259 (seeFIGURE 9). The blank safety joint barrel 258 has guide arms 260 of thetype heretofore described and is run in and latched in place with acombination setting and releasing tool 262 supported by a pipe string263 extending from vessel 20. With the Christmas tree closed by barrel258 locked with mandrel We, the pipe string and setting and releasingtool are brought back aboard the vessel, and the upper ends of the guidecables 67, 68, together with the release cable 259 are attached to asuitable marker buoy 260. Cables and marker buoy are then cast away fromves- The tubular conduits 218a, 221a, 225a, or hoses, through whichhydraulic fluids for operation of the remote operated valves 218, 221,225 are supplied, may be connected to buoy 260 as shown in FIGURE 10 foroperation by facilities aboard a vessel floated to the buoy, or mayextend to a base of operations on shore or afloat (not shown) havingsuch facilities. The

mooring lines of the vessel can then be taken in, and

the vessel floated away from the well site with the marker buoy servingto indicate the location of the well site and thereby providing means ofrelocating and retrieving the guide cables and re-entering the well, themarker buoy not being fixed, and thus not constituting a hazard tonavigation. p

In FIGURES 11 and 12 there are shown alternate forms of submarine basesfor the well which may be used instead of the base shown in FIGURES 1-2.1 The base shown in FIGURE 11 is of circular fabricated steel trussconstruction, having upper and lower ring elements 255, 266 andconnecting vertical angular bracing elements 257, 268. This base may beenclosed with steel plate welded on to close the framework in order tomake the base buoyant.

The second alternative form of base is shown in FIG- URE 12. This formof base is of the type disclosed buoyant or non-buoyant, sothat thedrums may be completely controlled from the surface. Such means isconventional. The lines 33, 34 (see FIGURE 2) are secured to the basefor lowering of the base from vessel 20 and for lowering of the initialequipment to the base, as in the other embodiment. Frame 273 provides anupper surface 275 upon which the ring 62 is landed.

Referring again to FIG. 11, an upper structure is shown attached to theframework base. This structure includes vertical members 289 reinforcedby diagonal braces 231, the entire structure being unitarily weldedtogether and to ring 265. A cylindrical ring 282 of tubular cylindricalshape formed of steel plate is welded within the upper ends of thevertical members 289. An upwardly diverging funnel 283 also formed ofstcel'plate serves to guide the entrance of the blowout control assembly'76, or other equipment, to within the frame structure. The centeringarms 2%, of which a plurality are provided in radial dispostion, havevertical tubular end parts 287 which carry outwardly facing Springs 288,the springs engaging 'the interior of ring 282 to hold the blowoutpreventer assembly in centered position. The rods 239 and turnbuckles 2%provide means for interconnecting and supporting the blowout preventerarms 101 (FIGURE 4B) two of the arms 236 which engage the guide cables84, 85, the arms 2% engaging the guide cables 67, 68 at end parts 287which slidingly surround'the cables.

The apparatus of this invention also provides for access to the. annularspaces between casing strings and between tubing and casing strings.Referring particularly to FIG- URES 7A and 7B, lateral ports 292 and 293are provided through the wall of casing head body at points below eachof the casing hangerseats 191, 192. These ports and their relationshipto the annular spaces between casing strings are further illustrated inFIGURES 7C and 7D. Ports 292, 293 are connected totubes 294, 295, respectively, which, in turn, are connected to a remote annular accessconnection device 297 through hydraulic operated valves 298, 299(FIGURES 7A, 7B). The annular access connection 297 includes acylindrical body 301 having a series of circular annular receptacles orseats 323-355 of successively decreasing diameter and arranged in astair-step manner. The uppermost circular receptacle 3% has a sidewallgroove 307 into which extendable latchinglugs of a mandrel 308 seat. Thesuccessively lower circular receptacles have circular grooves 310-312around their vertical sides to which are connected fluid passages313-315 through body 234. Fitting into and sealing within all of thereceptacles is the mandrel 328 having shoulders of successivelyincreasing diameter corresponding with the receptacles or seats 303-306.O-ring seals are installed in grooves around each stairstep wall portionof mandrel 308 to seal about each groove 3ltl- 312. These O-rings serveto seal-off the grooves within the successively smaller circularreceptacles, one from the other, thereby providing continuity betweenfluid passages 313-315 within body 301 and respective fluid passages317-319 through mandrel 308.

Body 301 is mounted upon a horizontal plate 361:: which has an openingdisposed about the tubular lower part of funnel 193, plate 391a beingsecured thereto as by welding. A reinforcing, or brace, plate 193:! isdisposed in a vertical plane and is welded at its edges to funnel 193,plate 361a, and to a side of body 391. Mandrel 3-98 is lowered on a pipestring or wire line (not shown) and positioned over body 3M by an offsetguide arm (not shown) riding along guide cables 84 and 85. The ofisetguide is similar to the several guide arms already described (guide arm43,"FIGURE 1; guide arms 1%, 13h, FIGURE 4A, etc.). However the offsetguide includes a lateral arm extending not to the guide cables but to apoint centered of body 361, so that mandrel 308 is guided into body 301.

Once in position a portion of the weight of the lowering apparatus isplaced on a latch actuator 329, causing the latching lugs of mandrel 308to engage groove 307. With the mandrel thus in place, hydraulic fluid ispumped under pressure through hoses 322-324 into the passages in mandrel308 and body 301, and on into the hydraulic opening valves 298, 299 toopen them. When these valves are opened, access to the desired annularspaces is provided through the connection and up into hoses 323, 324which, with pressure hose 322, extend to vessel 20. With access thusprovided to the annular spaces between the casing strings and tubing,pressures in these spaces can be determined or bled ofi, fluid or cementmay be pumped into the spaces, and other operations in connection withthese spaces carried out.

After such operations have been carried out, and if it is desirable, theannular spaces can again be sealed off.

To do this, the hydraulic pressure on the access valves is released,allowing these valves to be closed by automatic spring actuators. Withthe access tubes 323, 324 thus closed, mandrel 308 can be unlatched andraised to the surface by hoisting on the mandrel supporting apparatus.The latch actuator 320 is raised, permitting thelatch lugs to recedeinto the mandrel body by the action of return springs (not shown). Themandrel 308, together with its associated equipment, is then raised tovessel 20 by the banding apparatus.

To protect the interior sealing surfaces of connection body 301 fromcorrosive action and marine growth, a blank mandrel (not shown) may besealed and latched in place within connection body 301 in a mannersimilar to that described for mandrel 308. The blank mandrel is similarin construction to mandrel 241 except that it has no internal fluidpassages or hoses connected between it and the vessel. When the blankmandrel has been latched in place, the handling apparatus may bereleased from handling string connection groove 329 around latchactuator 320 and retrieved to the surface, leaving the connection closedand sealed from exposure to corrosion and marine growth. Re-entry to theconnection'is gained by lowering the handling apparatus back over thelatch actuator and removing the blank mandrel.

Referring again to FIGURES 7C, 7D of the drawings, the alternativeembodiment wherein the outer, or surface, casing in the well is ofreduced size has not yet been entirely described in detail. The firstdescribed embodiment, that of'FIGURES 7A, 7B, includes surface casingstring 56 within which is disposed concentrically a second casing string155. Also, as has been described, the casing strings 195, 196 and thetubing string 197 may be supported within casing string 155, FIGURES 7A,7B, in the manner shown in FIGURES 7C, 7D, so that the completeembodiment of FIGURES 7A, 7B will include casing strings 56, 155, 195,196 and tubing string 197, or as many of these as it is desirable orappropriate to include.

In the FIGURE 7C, 7D embodiment, casing string 155, which is of smallersize than casing string 56 (FIGURE 7B), is the outermost, or surface,casing string to which the supporting means for inner casing strings andthe tubing string are connected. In the FIGURE 7C, 7D embodiment, thecasing and tubing support assembly is lowered into place attached to theupper end of easing string 155, whereas in the FIGURE 7A, 7B embodiment,assembly 61 was lowered into place connected to the larger casing string56.

In FIGURES 7C, 7D, there is shown an adapter ring 331, or mandrel havingthreaded socket formation 332 at its lower end and having externalthreaded pin formation 333 of larger diameter at its upper end. Socket332 is screwed onto the upper end threads of string 155. Upper casinghead body 190 having intern-a1 seats 191, 192, previously described inconnection with FIGURES 7A, 7B, is threaded onto the pin 333 of adapter331.

Hangers 165a, 1651; have already been described in connection with theFIGURE 7A, 7B embodiment, as

14 has also the remainder of the apparatus shown in FIG- URES 7C, 7D.

While preferred embodiments of the invention have been shown anddescribed, many modifications of the methods and apparatus according tothe invention may be made by a person skilled in the art withoutdeparting from the spirit of the invention, and it is intended toprotect by Letters Patent all forms of the invention falling within thescope of the following claims.

We claim:

1. Well completion apparatus for underwater wells, comprising a casingextending from the top of the well downwardly thereinto, connectionmeans carried at the upper end of said casing, valve means havingcooperable connection means at its lower end cooperatingly joined withsaid casing connection means, handling means extending from saidconnection means to the water surface, said casing connection means andsaid valve means having cooperable connection means being connectibleand dis connectible by manipulation of said valve means by said handlingmeans provided to extend therefrom to the water surface so that saidvalve means may be connected and disconnected from the water surface, apipeline terminating at a point spaced along the floor of the body ofwater from the well, .a flexible conduit means connected with said valvemeans and extending along the floor of the body of water and connectedwith said pipeline for fluid flow from within said casing through saidvalve means into said pipeline, said flexible conduit means being ofsufficient length to permit movements of said valve means between itssaid connection at said casing connection means and the water surface,whereby said valve means may be connected to and disconnected from saidcasing from the water surface and moved between the water surface andthe well by said handling means without disconnection of said connectionthrough said flexible conduit means between said valve means andpipeline.

2. The combination of claim 1, said valve means comprising a mastervalve means having said cooperable connection means at its lower end, amember having a vertical flow passage and a lateral passage therefromconnected to surmount said master valve means, a wing valve meansconnected to said lateral passage, a connection between said wing valvemeans and said flexible conduit means, closure means in said verticalpassage above said lateral passage removable from the Water surface bysaid handling means, hydraulic operation means for said master valvemeans and for said wing valve means disposed adjacent thereto, hydraulicconduit means extending from said hydraulic operation means to alocation remote from the well for operation of said valve means tocontrol pressures within and fluid flow of the well from said remotelocation.

3. The combination of claim 1, including relatively heavy base meansincluding penetrating means at its lower surface for penetrating theunderwater surface of the earth around said casing, and means connectingsaid base means to said casing below said connection means at the upperend of said casing.

4. Combination of claim 1, including flexible line means extending fromsaid connection means at the upper end of said casing to the watersurface, said cooperable connection means of said valve means havingslidable connection with said flexible line means whereby said valvemeans when disconnected from said casing connection means may be movedby said handling means slidingly along said flexible line means betweenthe water surface and the well.

5. Combination of claim 4, including float means at the water surfacesupporting the upper end of said flexible line means.

6. Combination of claim 2, including flexible line means extending fromsaid connection means at the upper end of said casing to the watersurface, said cooperable connection means of said valve means havingslidable'connection with said flexible line means whereby said valvemeanswhen disconnected from said casing connection means may be moved bysaid handling means slidingly along said flexible line means between thewater surface and the well; and including float means at the 5 Watersurface supporting the upper end of said flexible line means; saidl-ocation remote from the Well to which said hydraulic conduit meansextend being at the water surface and said float means also supportingthe upper end of said hydraulic conduit means at the Water surface. 10

References Cited by the Examiner UNITED STATES PATENTS 16 Dunbar 175-10Kinniear 166-27 Hansen 175-10 Grace et a1 166-66.5 Plummer 175-210 XVoorhees 175-8 Tucker 175-6 McNeill 175-7 Bauer 175-7 Kofahl 175-7 Baueret a1 175-7 Knox 166-75 Frick 175-7 1,057,789 4/13 Wigle 166-27 15CHARLES E. OCONNELL, Primary Examiner.

Allcsting Officer UNITED STATES PATENT OFFICE CERTIFICATE OF CORRECTIONPatent No, 3,186,486 June 1, 1965 Allen F. Rhodes et a1.

It is hereby certified that error appears in the above numbered pat entreqliring correction and that the said Letters Patent should read ascorreotedbelow.

Column 1, before line 10, insert the following paragraph:

This application is a continuation-in-part of application Ser. No.695,955, filed by the same applicants on Nov. 12, 1957, and nowabandoned.

Signed and sealed this 19th day of October 1965.

(SEAL) Attest:

ERNEST W. SWIDER EDWARD J. BRENNER Commissioner of Patents

1. WELL COMPLETION APPARATUS FOR UNDERWATER WELLS, COMPRISING A CASINGEXTENDING FROM THE TOP OF THE WELL DOWNWARDLY THEREINTO, CONNECTIONMEANS CARRIED AT THE UPPER END OF SAID CASING, VALVE MEANS HAVINGCOOPERABLE CONNECTION MEANS AT ITS LOWER END COOPERATINGLY JOINED WITHSAID CASING CONNECTION MEANS, HANDLING MEANS EX-D TENDING FROM SAIDCONNECTION MEANS TO THE WATER SURFACE, SAID CASING CONNECTION MEANS ANDSAID VALVE MEANS HAVING COOPERABLE CONNECTION MEANS BEING CONNECTIBLEAND DISCONNECTIBLE BY MANIPULATION OF SAID VALVE MEANS BY SAID HANDLINGMEANS PROVIDED TO EXTEND THEREFROM TO THE WATER SURFACE SO THAT SAIDVALVE MEANS MAY BE CONNECTED AND DISCONNECTED FROM THE WATER SURFACE, APIPELINE TERMINATING AT A POINT SPACED ALONG THE FLOOR OF THE BODY OFWATER FROM THE WELL, A FLEXIBLE CONDUIT MEANS CONNECTED WITH SAID VALVEMEANS AND EXTENDING ALONG THE FLOOR OF THE BODY OF WATER AND CONNECTEDWITH SAID PIPELINE FOR FLUID FLOW FROM WITHIN SAID CASING THROUGH SAIDVALVE MEANS INTO SAID PIPELINE, SAID FLEXIBLE CONDUCIT MEANS BEING OFSUFFICIENT LENGTH TO PERMIT MOVEMENTS OF SAID VALVE MEANS BETWEEN ITSSAID CONNECTION AT SAID CASING CONNECTION MEANS AND THE WATER SURFACE,WHEREBY SAID VALVE MEANS MAY BE CONNECTED TO AND DISCONNECTED FROM SAIDCASING FROM THE WATER SURFACE AND MOVED BETWEEN THE WATER SURFACE ANDTHE WELL BY SAID HANDLING MEANS WITHOUT DISCONNECTION OF SAID CONNECTIONTHROUGH SAID FLEXIBLE CONDUIT MEANS BETWEEN SAID VALVE MEANS ANDPIPELINE.